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Questerre reports over 60% increase in reserves

THIS NEWS RELEASE IS NOT FOR DISSEMINATION OR DISTRIBUTION IN THE UNITED STATES OF AMERICA TO UNITED STATES NEWSWIRE SERVICES OR UNITED STATES PERSONS

CALGARY, Alberta, March 19, 2019 (GLOBE NEWSWIRE) -- Questerre Energy Corporation (“Questerre” or the “Company”) (TSX,OSE:QEC) reported today on the results of its December 31, 2018 Reserves Assessment and Evaluation of its Oil and Natural Gas Properties (the “Report”), as evaluated by McDaniel & Associates Consultants Ltd.(“McDaniel”) with an effective date of December 31, 2018, prepared in accordance with the standards contained in the Canadian Oil and Gas Evaluation Handbook (the “COGE Handbook”) and National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (“NI 51-101”). This Report does not include any assessment of contingent or prospective resources attributable to the Company’s properties.

Michael Binnion, President and Chief Executive Officer, commented, “The results from Kakwa North contributed to a significant increase in our reserves. Corporate proved and probable reserves grew by 63% or 11.5 MMBoe to 29.96 MMBoe, net of production during the year. The before tax NPV-10% estimated for the corporate proved and probable reserves using the average price forecast of three reserve engineering firms is $228.95 million.”

He added, “We are very encouraged by the results from Kakwa North and the potential for developing multiple Montney intervals. Currently we are being assigned reserves for only two intervals in the Montney but this acreage is also prospective for the Lower Montney where there are several tests in the area. We were also recently notified by an industry operator of their plans to license two multi-well pads for up to 54 wells directly offsetting one of our farm-in wells at Kakwa North.”

In accordance with the requirements of NI 51-101, the Company anticipates filing its Annual Information Form that includes more detailed disclosure relating to petroleum and natural gas activities for the 2018 fiscal year, in the form of Form 51-101F1, at the end of March 2019 as set out in the Report.

The following tables set forth contain certain information relating to the oil and natural gas reserves of the Company’s properties and the present value of the estimated future net cash flow associated with such reserves as at December 31, 2018, which numbers may vary slightly from those presented in the Report due to rounding. Also, due to rounding, certain columns may not add exactly.

The price forecast employed by McDaniel in estimating Questerre’s reserves is based on the average of commodity price forecasts effective January 1, 2019, from three qualified reserves evaluators who are independent of the Company, being GLJ Petroleum Consultants, Sproule Associates Ltd., and McDaniel’s (each of which is available on their respective websites at www.gljpc.com, www.sproule.com and www.mcdan.com).


SUMMARY OF OIL AND GAS RESERVES
FORECAST PRICES AND COSTS AS OF DECEMBER 31, 2018


  LIGHT AND
MEDIUM CRUDE OIL
CONVENTIONAL
NATURAL GAS
SHALE
GAS
NATURAL GAS
LIQUIDS
RESERVES CATEGORY Gross(1)
(Mbbl)
  Net(2)
(Mbbl)
  Gross(1)
(MMcf)
  Net(2)
(MMcf)
  Gross(1)
(MMcf)
  Net(2)
(MMcf)
  Gross(1)
(Mbbl)
  Net(2)
(Mbbl)
                               
Proved                              
Developed Producing 1,040.3   992.0   91.0   80.1   6,723.8   6,415.6   1,180.3   922.5
Developed Non-Producing 11.5   8.4   51.8   47.7   479.7   633.6   38.0   44.9
Undeveloped -   -   -   -   41,424.6   38,317.8   5,443.0   4,611.2
Total Proved 1,051.8   1,000.5   142.8   127.8   48,628.1   45,367.0   6,661.3   5,578.6
                               
Probable 1,062.0   1,003.9   80.7   71.7   44,439.6   40,152.5   5,535.8   4,172.8
Total Proved Plus Probable 2,113.8   2,004.4   223.5   199.5   93,067.6   85,519.5   12,197.1   9,751.4

(1)   Gross reserves are working interest reserves before royalty deductions.
(2)   Net reserves are working interest reserves after royalty deductions plus royalty interest reserves.
(3)   Natural Gas Liquids include condensate volumes.

SUMMARY NET PRESENT VALUES OF FUTURE NET REVENUE
FORECAST PRICES AND COSTS AS OF DECEMBER 31, 2018

  BEFORE INCOME TAXES DISCOUNTED AT
  AFTER INCOME TAXES DISCOUNTED AT
  UNIT VALUE
  (%/YEAR)
  (%/YEAR)
  BEFORE TAX
RESERVES 0%   5%   10%   15%   20%   0%   5%   10%   15%   20%   @ 10%(1)
CATEGORY  (M$)   (M$)   (M$)   (M$)   (M$)   (M$)   (M$)   (M$)   (M$)   (M$)   ($/BOE)
                                           
Proved                                          
Developed Producing 75,673.4   61,314.5   51,190.9   43,914.8   38,522.9   75,673.4   61,314.6   51,190.9   43,914.8   38,522.9   17.08
Developed Non‑Producing 2,892.4   2,361.8   1,994.8   1,736.2   1,548.1   2,892.4   2,361.8   1,994.8   1,736.2   1,548.1   11.96
Undeveloped 149,086.7   89,145.7   52,680.2   29,605.9   14,482.7   149,086.7   89,145.7   52,680.2   29,605.9   14,482.7   4.79
Total Proved 227,652.5   152,822.1   105,865.9   75,256.9   54,553.7   227,652.5   152,822.1   105,865.9   75,256.9   54,553.7   7.48
                                           
Probable 300,560.6   185,071.2   123,082.0   86,796.5   63,998.0   243,909.0   155,541.5   106,474.8   76,885.4   57,798.4   10.36
Total Proved Plus Probable 528,213.1   337,893.3   228,948.0   162,053.4   118,551.7   471,561.5   308,363.6   212,340.8   152,142.3   112,352.0   8.79

(1)   The unit values are based on net reserve volumes.
(2)   The estimated future net revenue from the production of disclosed oil and gas reserves does not represent fair market value of the Company’s reserves. There is no assurance that such price and cost assumptions will be attained and variances can be material.

   
SUMMARY OF PRICE FORECASTS  
                     
Year 2019 2020 2021 2022 2023 2024 2025 2026 2027 Thereafter
AECO Spot Price ($/MMBtu) 1.88 2.31 2.74 3.05 3.21 3.31 3.39 3.46 3.54 2%
Edmonton Light Crude Oil ($/bbl) 67.30 75.84 80.17 83.22 85.34 87.33 89.50 91.89 93.76 2%
Edmonton Condensate & Natural Gasoline ($/bbl) 70.10 79.21 83.33 86.20 88.16 90.20 92.43 94.87 96.80 2%
 

Questerre Energy Corporation is leveraging its expertise gained through early exposure to shale and other non-conventional reservoirs. The Company has base production and reserves in the tight oil Bakken/Torquay of southeast Saskatchewan.  It is bringing on production from its lands in the heart of the high-liquids Montney shale fairway. It is a leader on social license to operate issues for its Utica gas discovery in the St. Lawrence Lowlands, Quebec. It is pursuing oil shale projects with the aim of commercially developing these significant resources.

Questerre is a believer that the future success of the oil and gas industry depends on a balance of economics, environment and society. We are committed to being transparent and are respectful that the public must be part of making the important choices for our energy future.

For further information, please contact:

Questerre Energy Corporation
Jason D’Silva, Chief Financial Officer
(403) 777-1185 | (403) 777-1578 (FAX) |Email: info@questerre.com

Advisory Regarding Forward-Looking Statements

This news release contains certain statements which constitute forward-looking statements or information (“forward-looking statements”) including the Company’s view on the potential for developing Montney intervals, the prospectivity of Kakwa North for the Lower Montney, its estimated future net revenues, price forecasts and the filing of an Annual Information Form. In addition, statements relating to reserves and resources are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future.

Forward-looking statements are based on a number of material factors, expectations or assumptions of Questerre which have been used to develop such statements and information, but which may prove to be incorrect. Although Questerre believes that the expectations reflected in these forward-looking statements are reasonable, undue reliance should not be placed on them because Questerre can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Further, events or circumstances may cause actual results to differ materially from those predicted as a result of numerous known and unknown risks, uncertainties, and other factors, many of which are beyond the control of the Company, including, without limitation: whether the Company's exploration and development activities respecting its prospects will be successful or that material volumes of petroleum and natural gas reserves will be encountered, or if encountered can be produced on a commercial basis; the ultimate size and scope of any hydrocarbon bearing formations on its lands; that drilling operations on its lands will be successful such that further development activities in these areas are warranted; that Questerre will continue to conduct its operations in a manner consistent with past operations; results from drilling and development activities will be consistent with past operations; the general stability of the economic and political environment in which Questerre operates; drilling results; field production rates and decline rates; the general continuance of current industry conditions; the timing and cost of pipeline, storage and facility construction and expansion and the ability of Questerre to secure adequate product transportation; future commodity prices; currency, exchange and interest rates; regulatory framework regarding royalties, taxes and environmental matters in the jurisdictions in which Questerre operates; and the ability of Questerre to successfully market its oil and natural gas products; changes in commodity prices; changes in the demand for or supply of the Company's products; unanticipated operating results or production declines; changes in tax or environmental laws, changes in development plans of Questerre or by third party operators of Questerre's properties, increased debt levels or debt service requirements; inaccurate estimation of Questerre's oil and gas reserve and resource volumes; limited, unfavourable or a lack of access to capital markets; increased costs; a lack of adequate insurance coverage; the impact of competitors; and certain other risks detailed from time-to-time in Questerre's public disclosure documents. Additional information regarding some of these risks, expectations or assumptions and other factors may be found under in the Company's Annual Information Form for the year ended December 31, 2017 and other documents available on the Company’s profile at www.sedar.com. The reader is cautioned not to place undue reliance on these forward-looking statements. The forward-looking statements contained in this news release are made as of the date hereof and Questerre undertakes no obligations to update publicly or revise any forward-looking statements, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.

All evaluations and reviews of future net revenue are stated prior to any provision for interest costs or general and administrative costs and after the deduction of estimated future capital expenditures for wells to which reserves have been assigned. The estimated future net revenue from the production of disclosed oil and gas reserves does not represent the fair market value of the Company’s reserves. There is no assurance that such price and cost assumptions will be attained and variances could be material. The recovery and reserve estimates of crude oil, NGLs and natural gas reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered.

Actual light and medium crude oil, shale gas and natural gas liquids reserves may be greater than or less than the estimates provided herein. All the Company’s light and medium crude oil, shale gas and natural gas liquids reserves are located in Canada.

Barrel of oil equivalent (“boe”) amounts may be misleading, particularly if used in isolation. A boe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil and the conversion ratio of one barrel to six thousand cubic feet is based on an energy equivalent conversion method application at the burner tip and does not necessarily represent an economic value equivalent at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalent of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

The estimates of reserves and future net revenue for individual properties may not reflect the same confidence level as estimates of reserves and future net revenue for all properties, due to the effects of aggregation.